Petroleum drilling simulation experiment device and method

Abstract

The invention belongs to the technical field of petroleum drilling simulation experiment equipment, and particularly relates to a petroleum drilling simulation experiment device and method.The petroleum drilling simulation experiment device comprises a simulation wellbore filled with rock debris; the high-temperature and high-pressure control unit comprises a heating coil arranged on the outer wall of the simulation shaft in a sleeving mode and a high-pressure gas circuit assembly connected with the simulation shaft; the tripping simulation unit comprises a rotary driver, a linear moving assembly and a simulation drill rod, the simulation drill rod is arranged in the simulation shaft in a penetrating mode, the rotary driver is arranged at the output end of the linear moving assembly, and the simulation drill rod is connected with the rotary driver; the hole drift angle adjusting unit comprises a lifting assembly and a supporting seat, the simulation shaft and the linear moving assembly are both arranged on the supporting seat, and the lifting assembly is connected with the supporting seat; and the output end of the drilling fluid filling unit is communicated with the simulation shaft. According to the invention, multi-working-condition and multi-factor coupled complex well conditions in actual well drilling can be simulated, deep stratum environment conditions are accurately restored, and the accuracy of experimental parameters is improved.

Description

TECHNICAL FIELD

[0001] The present application belongs to the technical field of oil drilling simulation experiment equipment, and particularly relates to an oil drilling simulation experiment device and method. BACKGROUND

[0002] With the development of unconventional oil and gas resources to deep strata, complex well types such as multi-lateral horizontal wells and high-inclination wells have become key technical means to improve recovery. During drilling of these well types, the drill string is prone to form an eccentric annulus due to gravity sinking in the horizontal section and the inclined section, leading to accumulation of a cuttings bed and causing accidents such as high torque and pipe sticking; and the high temperature and high pressure environment of deep strata changes the rheological properties of drilling fluid and the cuttings transport law, further exacerbating the downhole risks.

[0003] Although the existing related experimental devices have functions of well inclination simulation, friction measurement, cuttings bed influence analysis or cuttings transport observation, when simulating the well type state, these devices are generally limited by the directional design of the structure, and after the experimental device is built, it can only be used for experiments with preset well types and environmental parameters, and it is difficult to simulate the complex well conditions of multiple working conditions and multiple factor coupling in actual drilling, and it is impossible to accurately restore the environmental conditions of deep strata, especially the dynamic changes of high temperature and high pressure conditions, resulting in a large deviation between the parameters obtained in the experiment and the actual drilling parameters, and it is impossible to provide reliable data support for the key technology research and development of deep oil drilling. SUMMARY

[0004] In order to solve the problems existing in the prior art, the purpose of the present application is to provide an oil drilling simulation experiment device and method, which can simulate the complex well conditions of multiple working conditions and multiple factor coupling in actual drilling, accurately restore the environmental conditions of deep strata, improve the accuracy of experimental parameters, and provide reliable data support for the key technology research and development of deep oil drilling.

[0005] The technical scheme of the present application is as follows: An oil drilling simulation experiment device, comprising a simulated wellbore, which is filled with cuttings for simulating a cuttings bed, and further comprising: A high temperature and high pressure control unit, comprising a heating coil sleeved on the outer wall of the simulated wellbore and a high pressure gas path assembly connected with the simulated wellbore, the heating coil being used for simulating the temperature in the well, and the high pressure gas path assembly being used for simulating the gas pressure in the well; A tripping simulation unit, comprising a rotary driver, a linear movement assembly and a simulated drill pipe, the simulated drill pipe being movably arranged in the simulated wellbore, the rotary driver being fixed on the output end of the linear movement assembly, and one end of the simulated drill pipe extending out of the top end of the simulated wellbore and being coaxially connected with the output shaft of the rotary driver, the linear movement assembly being used for driving the simulated drill pipe to move along the axial direction of the simulated wellbore, and the rotary driver being used for driving the simulated drill pipe to rotate; The well inclination angle adjusting unit comprises a lifting assembly and a support base, the simulation wellbore and the linear moving assembly are arranged on the support base, and the output end of the lifting assembly is hinged to one end of the support base, so as to change the inclination angle of the simulation wellbore by adjusting the lifting height of the one end of the support base. The drilling fluid filling unit is in sealed communication with the simulation wellbore, and is used for injecting drilling fluid into the simulation wellbore.

[0006] Preferably, the high-pressure gas path assembly comprises: The high-pressure air compressor has an air inlet and an air outlet, and a pressure regulating valve is arranged on the air outlet of the high-pressure air compressor, which is used for adjusting the gas output pressure. The gas inlet end of the gas storage tank is in communication with the air outlet of the high-pressure air compressor, and the gas outlet end is in sealed communication with the simulation wellbore through a gas pipeline, which is used for outputting high-pressure gas.

[0007] Preferably, the air inlet of the high-pressure air compressor is provided with an air inlet pressure gauge for real-time monitoring of the air inlet pressure, and the air outlet is provided with an air outlet pressure gauge for real-time monitoring of the gas output pressure before pressure regulation.

[0008] Preferably, the linear moving assembly comprises: The rotary motor is fixed on the support base; The gear is sleeved and fixed on the output end of the rotary motor; The gear transmission platform comprises a rectangular frame and two racks fixed on opposite sides of the rectangular frame, respectively, the two racks are arranged in parallel with the simulation drill pipe, the gear is engaged with the two racks, and one end of the simulation drill pipe extending out of the simulation wellbore is fixed to the rectangular frame through a rotary driver; The guide rail is fixed on the support base, and the rectangular frame is in sliding connection with the guide rail.

[0009] Preferably, the processing unit further comprises a controller and a multi-source data acquisition module, the multi-source data acquisition module is used for acquiring the rotation speed, moving speed, air pressure and temperature inside the simulation wellbore of the simulation drill pipe, respectively, the controller is electrically connected with the rotary driver, the rotary motor, the pressure regulating valve and the heating coil, respectively, the controller is used for adjusting the parameters of the rotary driver, the rotary motor, the pressure regulating valve and the heating coil according to the feedback data of the multi-source data acquisition module, so as to realize closed-loop control of the parameters.

[0010] Preferably, the multi-source data acquisition module comprises a torque sensor, a tension and pressure sensor, a thermometer and a pressure gauge, the torque sensor and the tension and pressure sensor are arranged on the simulated drill pipe, the torque sensor is used to measure the rotating speed of the simulated drill pipe, the tension and pressure sensor is used to measure the moving speed of the simulated drill pipe, and the thermometer and the pressure gauge are arranged on the simulated wellbore respectively to measure the temperature and the air pressure in the simulated wellbore respectively.

[0011] Preferably, the hoisting assembly comprises: a fixed platform arranged above the support base and higher than the simulated wellbore; a winch arranged on the fixed platform and having a winding wheel; a rope, one end of which is connected to the winding wheel of the winch and the other end of which is fixed to one end of the support base, used to realize the lifting of one end of the support base through the forward and reverse rotation of the winch.

[0012] Preferably, a visual window is arranged on the sidewall of the simulated wellbore, the visual window is provided with a scale along a direction perpendicular to the axis of the simulated wellbore, the zero point of the scale is flush with the inner wall bottom of the simulated wellbore, and the scale is used to measure the height of the cuttings bed.

[0013] Preferably, a method for simulating oil drilling is realized based on any of the above devices and comprises the following steps: adjusting the lifting height of one end of the simulated wellbore through the cooperation of the hoisting assembly and the support base to realize that the inclination angle of the simulated wellbore reaches a preset value; injecting cuttings with a particle size of 0.1mm-4.0mm from one end of the simulated wellbore to form a cuttings bed at the bottom of the simulated wellbore, and simultaneously measuring the injection height of the cuttings to adjust the height of the cuttings bed to a target value; inputting the prepared drilling fluid with a density of 1.25g / cm 3~ 2.0g / cm 3 and a viscosity of 20mPa·s-27mPa·s into the simulated wellbore and filling the entire simulated wellbore; starting the heating coil to heat the simulated wellbore to a target temperature, and starting the high-pressure gas path assembly to make the simulated wellbore reach a target high-pressure environment; setting the rotating speed and the moving speed of the simulated drill pipe, and sequentially starting the rotary driver and the linear moving assembly to drive the simulated drill pipe to move; every 2s-5s, using the multi-source data acquisition module to collect the tension and pressure and torque data in the drilling process of the simulated drill pipe, and recording the cuttings migration process in real time.

[0014] Preferably, the inclination angle ranges from 0° to 90°.

[0015] Compared with the prior art, the petroleum drilling simulation experiment device and method has the following beneficial effects: The present application solves the problems of single function and large parameter deviation of the existing experimental device by simulating the multi-factor coupling condition in the real drilling environment through integrated design, specifically: the high temperature and high pressure control unit simulates the temperature and pressure in the well through the heating coil and the high pressure gas path assembly respectively, and precisely controls the environmental parameters by using the electric heating effect and the gas compression characteristics to dynamically restore the high temperature and high pressure conditions of the deep formation; the tripping simulation unit drives the axial movement and rotation of the simulated drill pipe through the rotary driver and the linear movement assembly, and can simulate the movement of the simulated drill pipe under different parameter settings in the actual tripping process by using the controllability of the rotary driver and the linear movement assembly; the inclination angle adjusting unit changes the inclination angle of the simulated wellbore through the hinged structure of the hoisting assembly and the support seat, and covers the inclination range of 0° to 90° by using the lever principle and the height adjustment mechanism to simulate the annular state of the horizontal well or the high deviation well; the drilling fluid filling unit injects drilling fluid into the wellbore to simulate the influence of the fluid environment on the cuttings transport. Through the cooperative work of the above components, multi-parameter coupling control of temperature, pressure, inclination, cuttings bed height and drill string movement is realized, and the traditional device which can only simulate a single condition is broken through by principle optimization, thereby accurately restoring the complex well conditions and improving the reliability and consistency of the experimental data, providing high-fidelity data support for the research and development of deep petroleum drilling key technologies. BRIEF DESCRIPTION OF DRAWINGS

[0016] Figure 1 The present application is an overall structure schematic diagram in the embodiment thereof. Figure 2 The present application is a structure schematic diagram of the gear transmission platform in the embodiment thereof.

[0017] BRIEF DESCRIPTION OF DRAWINGS: 1, hoisting assembly; 2, servo motor; 3, torque sensor; 4, tension and pressure sensor; 5, exhaust hole; 6, heating coil; 7, temperature gauge; 8, pressure gauge; 9, torque and speed controller; 10, high pressure air compressor; 11, gas storage tank; 12, gear transmission platform; 13, water filling tank; 14, simulated wellbore; 15, simulated drill pipe; 16, inlet pressure gauge; 17, outlet pressure gauge; 18, pressure regulating valve; 19, viewing window; 20, rack; 21, guide rail; 22, gear. DETAILED DESCRIPTION

[0018] In order to make the purpose, technical scheme and advantages of the present application more clear and explicit, the present application will be further described in detail below in combination with the drawings and embodiments. It should be understood that the specific embodiments described herein are only used to explain the present application and do not limit the present application.

[0019] All other embodiments obtained by a person of ordinary skill in the art without creative labor based on the embodiments of the present application fall within the scope of protection of the present application.

[0020] In addition, the technical solutions among various embodiments of the present application can be combined with each other, but the combination of the technical solutions should be considered not to exist and not to be within the protection scope of the present application when the combination of the technical solutions appears contradictory or unachievable on the premise that a person of ordinary skill in the art can achieve the combination.

[0021] With the continuous development of unconventional oil and gas resources to deep formations, complex well types such as multi-lateral horizontal wells and highly deviated wells have become the key path to improve single well productivity and recovery. However, in the tripping operation of such well types, the drill string is prone to eccentric wall sticking in the horizontal section and the inclined section under the action of gravity, resulting in uneven annular flow channel, sedimentation and accumulation of cuttings to form a cuttings bed; and the high temperature (> 120℃) and high pressure (> 35MPa) environment commonly existing in deep formations significantly changes the viscosity, yield value and shear thinning characteristics of the drilling fluid, and affects the interfacial friction behavior between the cuttings particles and the well wall / drill pipe, thereby inducing engineering risks such as high friction, torque anomaly, sudden increase of circulating pressure loss, and even sticking. Although the existing experimental devices can simulate the change of well inclination angle, or carry out observation of cuttings migration under normal temperature and pressure, or carry out static friction measurement, they generally lack the ability to cooperatively control the temperature field and the pressure field, and the key subsystems such as well inclination angle adjustment, cuttings bed height control, drill string composite motion (axial + rotary) driving and dynamic drilling fluid injection are not structurally integrated and parameter coupled, which makes it difficult to reproduce the complex working conditions of the six-dimensional parameter strong coupling of "temperature-pressure-inclination-cuttings-liquid-motion" in the real drilling process of deep horizontal wells, resulting in poor extrapolation of experimental data and insufficient basis for process optimization.

[0022] To this end, the present application provides a petroleum drilling simulation experiment device.

[0023] Reference is made to Figure 1 and Figure 2As shown, the experimental device includes a simulated wellbore 14 filled with cuttings for simulating a cuttings bed, and further includes a high-temperature and high-pressure control unit, a tripping simulation unit, a well inclination angle adjusting unit, and a drilling fluid filling unit. The high-temperature and high-pressure control unit includes a heating coil 6 sleeved on the outer wall of the simulated wellbore 14 and a high-pressure gas path assembly connected with the simulated wellbore 14, the heating coil 6 is used for simulating the temperature in the well, and the high-pressure gas path assembly is used for simulating the gas pressure in the well; the tripping simulation unit includes a rotary driver, a linear movement assembly, and a simulated drill pipe 15, the simulated drill pipe 15 is movably arranged in the simulated wellbore 14, the rotary driver is a servo motor or a stepping motor and is fixed at the output end of the linear movement assembly, and one end of the simulated drill pipe 15 extends out of the simulated wellbore 14 and is coaxially connected with the output shaft of the rotary driver, the linear movement assembly is used for driving the simulated drill pipe 15 to move along the axial direction of the wellbore, and the rotary driver is used for driving the simulated drill pipe 15 to rotate; the well inclination angle adjusting unit includes a lifting assembly 1 and a support seat, the simulated wellbore 14 and the linear movement assembly are both arranged on the support seat, the output end of the lifting assembly 1 is hingedly connected with one end of the support seat, and the lifting height of the one end of the support seat is adjusted to change the inclination angle of the simulated wellbore 14; the output end of the drilling fluid filling unit is in sealed communication with the simulated wellbore 14, and is used for injecting drilling fluid into the simulated wellbore 14.

[0024] The core of the embodiment is to realize dynamic reproduction of the whole tripping process under the conditions of high temperature, high pressure, variable inclination, cuttings bed and drilling fluid medium by modular structure design and parameterized driving logic. The device takes the horizontally arranged simulated wellbore 14 as a physical carrier, establishes thermal and force boundary conditions relying on the high-temperature and high-pressure control unit, gives the simulated drill pipe 15 the composite motion ability of axial displacement and circumferential rotation by means of the tripping simulation unit, flexibly reconstructs different well profile geometric constraints in combination with the well inclination angle adjusting unit, and introduces fluid dynamics variables through the drilling fluid filling unit, so as to construct a multi-field coupling experimental environment with high fidelity, high controllability and high repeatability on the laboratory scale.

[0025] The simulation wellbore 14 is a closed tubular structure with its axis horizontally arranged, which can be made of 316L stainless steel with high temperature and high pressure corrosion resistance, with an inner diameter ranging from 80mm to 150mm, a length of 2m to 5m, and high pressure sealing flanges at both ends. A multi-lip fluorine rubber sealing ring is assembled in the contact area of the flange and the simulation drill pipe 15, and is assisted by high temperature lubricating grease to form a dynamic sealing assembly, which ensures long-term stable operation under the condition of 150°C and 40MPa. The cuttings are quartz sand or simulation core debris after screening treatment, with a particle size distribution of 0.1mm to 4.0mm, which is filled in the simulation wellbore 14 at the bottom according to the experimental requirements, to form a cutting bed with a controllable thickness (1mm to 50mm) to represent the wellbore cleaning state under different deposition degrees. The simulation wellbore 14 can also be replaced by a carbon steel cylinder lined with ceramic coating, or a local observation section made of transparent polycarbonate material to meet the requirements of structural strength and visualization.

[0026] The heating coil 6 in the high temperature and high pressure control unit is a spiral wound nickel-chromium alloy heating wire, which is uniformly coated in the middle area of the outer wall of the simulation wellbore 14. The outside of the coil is provided with a mica insulation layer and a stainless steel braided sheath. The power density is 1kW / m² to 3kW / m². The input current is adjusted by a PID temperature controller in a closed loop to realize continuous adjustment of the wellbore wall temperature in the range of room temperature to 200°C, with a temperature control accuracy of ±1.5°C. The high pressure gas path assembly is composed of three parts of gas source, pressure stabilizing and conveying. The gas source can be selected from a high pressure air compressor 10 or a nitrogen bottle group. The pressure stabilizing part includes a pressure regulating valve 18 and a buffer gas storage tank 11. The conveying pipeline is made of 316L stainless steel hard pipe with double sleeve joints. The working pressure range is 0.1MPa to 45MPa. Self-sealing quick connectors are provided at the interfaces for quick disassembly and assembly. The assembly can also be replaced by a hydraulic drive system, which uses high temperature heat conducting oil as medium to establish a static water pressure field through a plunger pump, which is suitable for rheological property research scenes that need to avoid the influence of gas compressibility.

[0027] The simulation drill pipe 15 in the tripping simulation unit is a solid cylindrical metal rod made of 42CrMo alloy steel with a diameter of 20mm to 40mm. The surface is treated by nitriding to improve wear resistance. The rotary driver is a combination of a servo motor 2 and a reducer, with a rated torque of ≥50N·m and a speed adjustment range of 0r / min to 300r / min, with position / speed / torque three closed loop control capability. The linear motion assembly is an electromechanical integrated linear actuator, which can be selected from a ball screw module, a gear 22 and a rack 20 platform, or an electric cylinder, with a travel accuracy better than ±0.05mm, a maximum thrust of ≥10kN, and a motion speed that can be adjusted steplessly between 0.1mm / s and 100mm / s. The simulation drill pipe 15 and the output shaft of the rotary driver are connected by involute spline or diaphragm coupling to ensure reliable transmission of torque and axial force.

[0028] The support seat in the well inclination angle adjusting unit is a rigid welded frame structure, a bottom is provided with adjustable supporting legs and a level meter, and is used for initial leveling; the lifting assembly 1 is a mechanical or electric hoist system, an output end (such as a steel rope, a chain or a hydraulic jack) of the lifting assembly 1 is hingedly connected with one end of the support seat through a pin shaft, and the hinged point is located near the longitudinal center line of the support seat, so that the lifting process is stable and free of torsion; by adjusting the lifting height, the angle between the simulated wellbore 14 axis and the horizontal plane can be continuously adjusted in the range of 0° (completely horizontal) to 90° (vertical), and the horizontal well, the high-inclination well and the vertical well in the actual well type are corresponded; the unit can also be replaced by a two-degree-of-freedom rotary platform, and any spatial attitude adjustment is realized through the linkage of the two axes of pitch and yaw, or a hydraulic support leg array is used to realize multi-point cooperative adjustment.

[0029] The drilling fluid filling unit comprises a liquid storage tank, a metering pump, a pressure regulating valve and a flexible delivery hose, the volume of the liquid storage tank is 5L-50L, the liquid storage tank is provided with a stirring paddle and a constant temperature jacket, the metering pump is a diaphragm type or a peristaltic type, the flow control accuracy is ±1%, and the maximum output pressure is greater than or equal to 5MPa; the delivery hose is connected to the bypass interface of the flange at one end of the simulated wellbore 14, a one-way valve and a pressure buffer cavity are arranged at the interface, and the one-way valve and the pressure buffer cavity are used to prevent backflow and water hammer impact; the unit can also be expanded into a double-channel filling system, which is connected to the two ends of the wellbore respectively, and the positive circulation and reverse circulation drilling fluid flow mode switching is realized. Preferably, the density of the drilling fluid is controlled to be 1.25g / cm 3~ 2.0g / cm 3 , and the viscosity is controlled to be 20mPa·s-27mPa·s.

[0030] The above units are nested with each other in spatial layout and functional logic: the simulated wellbore 14 is a shared bearing matrix, and simultaneously bears the load of the cuttings bed, the drilling fluid, the high temperature and high pressure medium and the drill pipe movement load; the support seat not only supports the simulated wellbore 14, but also fixes the linear movement assembly, so that the movement reference and the wellbore attitude are strictly synchronized; the lifting assembly 1 only acts on one end of the support seat, so as to avoid interference with the guiding accuracy of the linear movement assembly; the heating coil 6 and the high pressure gas path assembly respectively apply heat and pressure from the outside, and the two are independently controlled but jointly act on the same wellbore inner cavity to form a temperature and pressure coupling boundary; the drilling fluid filling unit is injected after the wellbore is sealed, and the liquid column height and the flow rate directly affect the critical flow rate of the cuttings suspension and the annular pressure consumption, and are in real-time interaction with the drill pipe movement state. The design of structure integration and parameter decoupling ensures that each physical field can be independently calibrated and coupled and loaded as needed.

[0031] Through the above technical solution, the present invention realizes the simultaneous construction of multi-dimensional constraint conditions such as high temperature, high pressure, variable well inclination angle, cuttings bed and drilling fluid medium on a single experimental platform, and drives the simulated drill pipe 15 to complete a composite motion with both axial displacement and circumferential rotation. For example, when simulating the tripping operation of a shale gas horizontal well with a vertical depth of 3500m and an inclination angle of 85°, one end of the support seat is first raised to the target inclination angle. Then, a 20mm thick bed of quartz sandstone cuttings is laid at the bottom of the simulated wellbore 14, and polymer drilling fluid with a density of 1.25g / cm³ and a viscosity of 20mPa·s is injected to fill the entire wellbore. Then, the heating coil 6 is activated to raise the temperature to 135°C, and the high-pressure gas circuit component is simultaneously activated to pressurize to 38MPa. After the temperature and pressure stabilize, the rotary drive speed is set to 120r / min, and the linear movement component is raised at a uniform speed of 20mm / s to lift the simulated drill pipe 15. During this process, the cuttings bed undergoes local resuspension and migration under the dual action of drilling fluid shear and drill pipe disturbance. Its accumulation morphology can be observed in real time through the viewing window 19, while the tension and torque on the drill pipe show a nonlinear growth trend with the increase of well inclination angle, the increase of cuttings bed thickness, and the increase of temperature and pressure. Because the simulated wellbore 14 possesses high-temperature and high-pressure bearing capacity, the heating coil 6 and high-pressure gas circuit assembly can independently and accurately reproduce the thermal-mechanical environment of deep formations. Due to the spatial coupling arrangement of the linear motion component and rotary actuator in the tripping simulation unit, the movement trajectory of the simulated drill pipe 15 strictly follows the wellbore axis, avoiding additional bending moment interference caused by eccentricity. Because the well inclination angle adjustment unit adopts a single-end hinged lifting method, the inclination angle adjustment does not change the reference coordinate system of the flow field inside the wellbore. Because the drilling fluid injection unit has pressure closed-loop control capability, it can maintain the dynamic balance between the annular hydrostatic column pressure and the gas pressure inside the wellbore. Therefore, this embodiment fundamentally solves the core problems mentioned in the background technology, such as "incomplete operating condition coverage, lack of temperature and pressure control, and limited adjustment of cuttings bed and tripping parameters," providing a quantifiable, repeatable, and traceable experimental basis for predicting the tripping safety window for deep and complex well types, verifying cuttings bed removal processes, and evaluating the performance of new drilling fluids.

[0032] See Figure 1 As shown, the high-pressure gas circuit assembly includes a high-pressure air compressor 10 and an air storage tank 11. The high-pressure air compressor 10 has an inlet and an outlet, and a pressure regulating valve 18 is provided on the outlet of the high-pressure air compressor 10 for regulating the gas output pressure; the inlet end of the air storage tank 11 is connected to the outlet end of the high-pressure air compressor 10, and the outlet end is sealed and connected to the simulated well shaft 14 through a gas transmission pipeline for outputting high-pressure gas.

[0033] As a key subsystem of the high-temperature and high-pressure control unit, the high-pressure gas circuit assembly's core function is to provide the simulated wellbore 14 with a gas source that offers pressure stability, adjustability, and process continuity. The high-pressure air compressor 10 can be a two-stage compression piston type with a rated exhaust pressure of no less than 25 MPa. The inlet is equipped with an air filter and dryer to remove moisture and particulate impurities from the intake air, preventing condensation or pipeline corrosion after moisture enters the high-temperature environment. The outlet integrates a built-in pressure regulating valve 18, which is a pilot-operated proportional pressure reducing valve driven by a diaphragm through a closed-loop electrical signal control. It has a pressure setting resolution of 0.01 MPa and a pressure stabilization accuracy better than ±0.03 MPa (FS), enabling stepless and smooth adjustment from atmospheric pressure to the target experimental pressure. A buffer chamber is located downstream of the pressure regulating valve 18 to further suppress minor step disturbances caused by the valve body's response inertia. The gas storage tank 11 is a vertical cylindrical pressure vessel with a volume of 200L~500L and a design pressure of 25 MPa. It is made of 16MnDR low-temperature high-strength steel, and the inner wall is sandblasted and passivated to eliminate stress concentration and improve pressure resistance reliability. Its air inlet is connected to the air outlet of the high-pressure air compressor 10 through a high-pressure hose. The connection uses a compression fitting to ensure zero leakage under dynamic operating conditions. The air outlet is led out through a seamless stainless steel pipe, and a shut-off valve and a safety relief valve are installed near the tank outlet. The gas transmission pipeline adopts a double-layer stainless steel corrugated pipe structure, with the inner layer bearing pressure and the outer layer shielding. Both ends are equipped with flanges to connect to the high-pressure interface of the simulated well shaft 14 side wall. The flange sealing surface is RTJ type, with elliptical cross-section stainless steel sealing rings to meet the sealing integrity under dual operating conditions of 350 ℃ high temperature and 15 MPa high pressure. The pressure difference between the gas storage tank 11 and the simulated wellbore 14 is precisely limited by the pressure regulating valve 18. The large volume of the gas storage tank 11 creates a "pressure flywheel" effect during gas supply—when the simulated wellbore 14 experiences instantaneous volume changes due to drill pipe movement (such as a decrease in annular volume caused by drill pipe insertion), the gas storage tank 11 can quickly release or absorb a small amount of gas, suppressing pressure fluctuations within the wellbore to within ±0.05 MPa (measured data), significantly better than the ±0.8 MPa fluctuation amplitude of the direct-connection gas supply scheme. Through the above technical solution, this invention achieves high-fidelity reproduction of the high-pressure environment within the simulated wellbore 14.

[0034] See Figure 1As shown, an inlet pressure gauge 16 is installed at the inlet of the high-pressure air compressor 10, and an outlet pressure gauge 17 is installed at the outlet. By configuring pressure monitoring instruments at the inlet and outlet of the high-pressure air compressor 10 respectively, a dual-point pressure feedback path is constructed to achieve independent, synchronous, and visual monitoring of the pressure status on the compressed gas source side and the output side. The inlet pressure gauge 16 is used to reflect the ambient air pressure at the air compressor intake end or the actual intake pressure after treatment by the pre-filter / drying unit in real time; the outlet pressure gauge 17 directly displays the instantaneous exhaust pressure at the outlet of the air compressor compression chamber, and monitors the gas output pressure before pressure adjustment in real time. Together, they constitute the basic parameter set for judging the operating condition of the air compressor. This configuration does not rely on the downstream pressure gauge 8 of the system, but focuses on the performance evaluation of the air compressor itself and the verification of the reliability of the front-end air supply, which belongs to the source-level state perception design of the high-pressure air circuit system. The intake pressure gauge 16 continuously monitors the front-end air supply capacity. When the reading is lower than the set lower limit (e.g., 0.08 MPa), it indicates that the air filter is clogged or the ambient air intake is insufficient. The outlet pressure gauge 17 maps the compression efficiency and load status in real time. If its reading is significantly higher than the set value of the pressure regulating valve 18 and continues to fluctuate, it indicates that the pressure regulating valve 18 is slow to respond or the valve core is stuck. The difference between the two can indirectly reflect the trend of changes in the internal volumetric efficiency of the air compressor, providing a quantitative basis for preventive maintenance.

[0035] Through the above technical solution, source-level, dual-dimensional pressure sensing of the operating status of the high-pressure air compressor 10 is achieved. The inlet pressure gauge 16 can promptly identify abnormalities in the upstream air source (such as filter blockage or inlet pipeline leakage), and the outlet pressure gauge 17 can independently verify whether the actual output pressure of the pressure regulating valve 18 meets the set value. The combination of the two forms a closed-loop verification relationship. When the pressure regulating valve 18 is adjusted, the change in the reading of the outlet pressure gauge 17 can be confirmed immediately, while the reading of the inlet pressure gauge 16 remains stable, indicating that the pressure regulation action is effective and has not caused upstream air supply disturbance. This achieves the technical effects of improving the operational safety of the high-pressure air circuit system, ensuring the accuracy of pressure control, and enhancing the ability to identify faults early.

[0036] See Figure 1 As shown, the linear motion assembly includes a rotary motor, a gear 22, a gear transmission platform 12, and a guide rail 21. The rotary motor is fixed to the support base. The gear 22 is mounted and fixed to the output end of the rotary motor. The gear transmission platform 12 includes a rectangular frame and racks 20 fixed to opposite sides of the rectangular frame. The two racks 20 are arranged parallel to the simulated drill pipe 15, and the gear 22 meshes with the two racks 20. One end of the simulated drill pipe 15 extending out of the simulated wellbore 14 is fixed to the rectangular frame via a rotary driver. The guide rail 21 is fixed to the support base, and the rectangular frame is slidably connected to the guide rail 21.

[0037] A mechanical transmission structure is adopted, in which a rotary motor drives a gear 22 and a rack 20 meshing on both sides of the gear 22 to move a rectangular frame along a guide rail 21. This achieves integrated control of high precision, low vibration, strong load-bearing capacity, and directional constraint for the axial movement of the drill pipe 15. Its core lies in the coordinated use of a rigid frame bearing, symmetrical meshing, and guide limit mechanism to ensure that the drill pipe movement trajectory strictly follows the axis of the simulated wellbore 14 during tripping in and out of the well, avoiding off-center loading, jamming, and nonlinear jumping, thereby improving the realism and data repeatability of cuttings movement simulation in horizontal or deviated well sections.

[0038] The rotary motor is either a servo motor 2 or a stepper motor. An AC servo motor 2 with a rated power of 0.75 kW to 2.2 kW and a rated speed of 1000 r / min to 3000 r / min can be selected. Its base is rigidly fixed to the reinforcing rib plate on the top of the support base by bolts, ensuring that no base vibration is transmitted to the entire transmission system during motor operation. The end of the motor output shaft is machined with a keyway or tapered hole structure for circumferential positioning and axial locking with gear 22. As an optional implementation, the rotary motor can also be replaced with a direct-drive torque motor with a gearbox, directly outputting high torque at low speed, eliminating the intermediate coupling link, and further reducing transmission chain errors and response delays. Gear 22 is an involute standard spur gear 22 or a helical gear 22. Gear 22 is fitted and fastened to the output shaft of the rotary motor by key connection or interference fit to ensure that no relative slippage occurs when transmitting torque. As an optional implementation, gear 22 can also adopt a double gear 22 structure, that is, two gears 22 with the same parameters are installed on the same shaft and mesh independently with the left and right racks 20 respectively, so as to enhance meshing rigidity and anti-eccentric load capacity. In addition, when helical gears 22 are used, the helix angle can be set to 8°~15°, which can improve meshing smoothness and offset part of the axial force, avoiding lateral force imbalance of guide rail 21. Gear 22 transmission platform 12 consists of a rectangular frame and two racks 20 fixed on opposite sides of it. The rectangular frame is a closed box-shaped structure welded from steel plates, and its top surface is provided with a T-slot for mounting the rotary drive base. The two racks 20 are arranged parallel to each other on the left and right outer walls of the rectangular frame along the length direction, and are strictly parallel to the axis of the simulated drill rod 15. One end of the simulated drill rod 15 extending out of the simulated wellbore 14 is fixedly connected to the rectangular frame via a rotary actuator. The rotary actuator is a hollow servo motor 2 or a hydraulic motor, the diameter of which is adapted to the outer diameter of the simulated drill rod 15 through the central through hole of its output shaft, and is rigidly connected to the top surface of the rectangular frame via a flange. After the simulated drill rod 15 passes through the central hole of the rotary actuator, it is double-clamped and fixed by an end locking ring and a radial set screw to ensure that the torque and axial force are transmitted synchronously and reliably. The guide rail 21 is vertically fixed to the upper surface of the support base by countersunk screws. A matching slider assembly is provided at the corresponding position at the bottom of the rectangular frame, forming a high-rigidity, low-friction sliding pair with the guide rail 21. The axis of the guide rail 21 and the axis of the simulated wellbore 14 are collinear in both the vertical and horizontal orthogonal planes, ensuring that the simulated drill rod 15 always feeds axially along the center line of the wellbore during the translation of the rectangular frame. As an optional implementation, the guide rail 21 can also adopt a composite structure of double-row parallel V-shaped guide rail 21 + flat guide rail 21, which utilizes the automatic centering characteristics of the V-shaped surface to enhance the guiding accuracy and is suitable for experimental scenarios with higher repeatability positioning accuracy requirements.

[0039] Through the above scheme, during the axial movement of the simulated drill pipe 15, a rotary motor is used as the power source. The rotational motion is converted into linear motion through the meshing of gear 22 and double-sided rack 20. The guide rail 21 provides a definite direction constraint for the motion. At the same time, with the overall rigid support of the rectangular frame and the coaxial connection of the rotary drive, it is ensured that the simulated drill pipe 15 remains highly coaxial with the axis of the simulated wellbore 14 throughout the entire stroke. Because the gear 22-rack 20 transmission has the characteristics of no elastic slip, constant transmission ratio, and fast dynamic response, combined with the precise guidance of the guide rail 21, the fluctuation rate of the tripping speed of the simulated drill pipe 15 is controlled within ±1.5%, and the displacement repeatability is better than ±0.05 mm. Furthermore, because the double-sided meshing structure cancels out the lateral resultant force, it significantly reduces the bending stress at the connection between the support and the guide rail 21, extends the service life of the equipment, and ensures the controllability, stability, and reproducibility of the axial motion parameters of the drill string during the tripping of horizontal wells. This provides a high-fidelity motion basis for the study of the dynamic evolution of the cuttings bed and friction law.

[0040] See Figure 1 As shown, it also includes a processing unit, which includes a controller and a multi-source data acquisition module. The multi-source data acquisition module is used to collect the rotational speed and moving speed of the simulated drill pipe 15 and the air pressure and temperature inside the simulated wellbore 14, respectively. The controller is electrically connected to the rotary drive, rotary motor, pressure regulating valve 18 and heating coil 6, respectively. The controller is used to adjust the parameters of the rotary drive, rotary motor, pressure regulating valve 18 and heating coil 6 according to the feedback information of the multi-source data acquisition module.

[0041] The controller is an industrial-grade programmable logic controller (PLC) or embedded microcontroller system (such as a real-time control platform based on the ARM Cortex-M7 core) with multi-channel input / output capabilities. It has a built-in PID regulation algorithm module and a preset operating condition database. The controller establishes a stable electrical connection with each actuator through standard industrial communication protocols (such as Modbus RTU or CANopen) and supports remote parameter configuration, operation status monitoring and abnormal alarm functions to meet the computing power and safety compliance requirements of different experimental scenarios. The multi-source data acquisition module is a distributed sensing subsystem composed of multiple heterogeneous sensors and their signal conditioning circuits. Its acquisition objects are strictly limited to the rotational speed and moving speed of the simulated drill pipe 15, and the air pressure and temperature inside the simulated wellbore 14. Specifically, the multi-source data acquisition module includes a torque sensor 3, a tension / compression sensor 4, a temperature gauge 7, and a pressure gauge 8. The torque sensor 3 and the tension / compression sensor 4 are both installed on the simulated drill pipe 15 to measure the rotational speed and moving speed of the simulated drill pipe 15, respectively. The temperature gauge 7 and the pressure gauge 8 are both installed on the simulated wellbore 14 to measure the temperature and air pressure inside the simulated wellbore 14, respectively.

[0042] The multi-source data acquisition module, acting as the perception layer, continuously acquires key process parameters and converts them into digital signals. The controller, acting as the decision-making and scheduling layer, performs real-time calculations on the acquired data based on preset control logic (such as incremental PID algorithms) to generate corresponding execution commands. The rotary actuator, rotary motor, pressure regulating valve 18, and heating coil 6, acting as the execution layer, receive commands and adjust their own working states, thereby changing the motion behavior of the simulated drill pipe 15 and the temperature and pressure environment inside the wellbore. This forms a closed-loop control circuit of "perception-decision-execution-re-perception". This structure does not rely on external manual intervention, and the response delay of each link is controlled at the millisecond level, ensuring that the system has the ability to quickly achieve steady-state recovery when facing typical experimental disturbances such as cuttings bed disturbances and sudden changes in drilling fluid rheology. It realizes the automated and coordinated control of core process parameters during the simulation of high-temperature and high-pressure horizontal well tripping.

[0043] Specifically, torque sensor 3 is used to measure the rotational speed of the simulated drill pipe 15. It should be clarified that "measuring rotational speed" refers to obtaining the rotational speed value by detecting the dynamic torque changes experienced by the drill pipe during rotation and then using a built-in algorithm in the controller; the actual physical measurement object is torque, and rotational speed is a derived parameter. Torque sensor 3 is a non-contact magnetoelectric coded torque sensor. Its core structure includes a stator coil group, a rotor permanent magnet ring, and a signal conditioning circuit. It is installed on the shaft section of the simulated drill pipe 15 near the output end of the rotary drive, achieving rigid coupling with the simulated drill pipe 15 through a keyway or interference fit. Furthermore, torque sensor 3 is controlled by torque-speed controller 9, facilitating the setting of initial torque parameters. Tension / compression sensor 4 is used to measure the moving speed of the simulated drill pipe 15. Similarly, "measuring moving speed" is actually obtained by continuously acquiring axial tension / compression loads and combining them with the displacement feedback signal of the linear motion component, which is then calculated by the controller to obtain the instantaneous axial movement rate; its direct measurement is axial force. The tension / compression sensor 4 is a column-type piezoelectric / piezoresistive composite tension / compression sensor 4, which is integrated at the connecting flange between the analog drill pipe 15 and the rotary actuator. The two ends of the sensor are respectively fixed to the threaded section at the tail of the drill pipe and the flange face of the output shaft of the actuator.

[0044] Both the temperature gauge 7 and the pressure gauge 8 are installed on the simulated wellbore 14. The temperature gauge 7 is a platinum resistance thermometer, which is inserted into the temperature measuring hole reserved in the side wall of the simulated wellbore 14. The temperature sensing end extends into the inner cavity of the wellbore, ensuring a fast response and free from electromagnetic interference from the heating coil 6. The pressure gauge 8 is a diaphragm-type high-precision digital pressure transmitter. Its isolation diaphragm is rigidly connected to the body of the simulated wellbore 14 through a threaded interface, and can be connected to a multi-source data acquisition module for unified clock synchronization sampling.

[0045] The sensing units are arranged in a hierarchical and collaborative manner in terms of spatial layout and functional logic: Torque sensor 3 and tensile / compressive force sensor 4 are coaxially mounted on the drill pipe, forming a mechanical sensing node in the "drill string body layer," which captures in real time the transient torque surge and axial resistance jump induced by non-uniform rock cuttings bed accumulation, eccentric contact with the wellbore, and material creep caused by temperature and pressure; Temperature gauge 7 and Pressure gauge 8 serve as monitoring terminals in the "environmental layer," providing background temperature and pressure reference values ​​and supporting the controller's online calibration of the friction coefficient temperature-pressure correction model; the data from both are synchronously sampled via the same acquisition instrument, ensuring the traceability of the causal relationship between mechanical response and environmental excitation. This arrangement strategy is not dependent on a specific well inclination angle or rock cuttings bed height and is suitable for consistent data acquisition under a full range of inclination conditions from 0° to 90°.

[0046] Through the above technical solutions, this invention achieves in-situ, synchronous, and multi-dimensional quantitative sensing of the dynamic behavior of the drill string and wellbore environmental parameters during the tripping in and out of high-temperature, high-pressure horizontal wells. Since the torque sensor 3 is directly coupled to the simulated drill pipe 15 and responds to its rotational mechanical state, it can sensitively capture the torque step generated when the drill pipe crosses the interface of cuttings beds of different densities, revealing potential stuck points. Because the tension and compression sensors 4 are arranged adjacent to the rotary actuator, they can accurately identify the abnormal increase trend of axial resistance caused by cuttings bed compaction or wellbore adhesion during tripping in and out of the well. The continuous monitoring of the thermodynamic state inside the wellbore by the temperature gauge 7 and pressure gauge 8 provides a basis for distinguishing between "pure mechanical stuck" and "temperature-pressure coupled frictional increase." The joint analysis of data from these four types of sensors allows this embodiment to significantly improve the physical completeness and engineering interpretability of experimental data through reasonable hardware configuration and spatial optimization, without introducing additional actuators or complex algorithms.

[0047] See Figure 1As shown, the lifting assembly 1 includes a fixed platform, a winch, and a rope. The fixed platform is positioned above the support base, higher than the simulated wellbore 14; the winch is mounted on the fixed platform and has a winding wheel; one end of the rope is connected to the winding wheel of the winch, and the other end is fixed to one end of the support base. The lifting assembly 1 involved in this embodiment is the core mechanical actuator for achieving continuous, stable, and repeatable adjustment of the inclination angle of the simulated wellbore 14. The technical essence lies in applying a controllable vertical displacement to one end of the support base by combining rigid support with flexible traction. Utilizing the hinge fulcrum formed by the other end of the support base and the ground (or base), the linear displacement is converted into rotational motion of the simulated wellbore 14 around its axis, thereby precisely controlling the spatial attitude of the wellbore. This structure abandons complex transmission forms such as hydraulic cylinder lifting and multi-link linkage, achieving a wide range and high repeatability of angle control with a simple mechanical configuration, while taking into account both engineering reliability and experimental operability. The fixed platform is a rigid load-bearing platform, welded from Q345B low-alloy high-strength structural steel, with an overall rectangular frame structure. The winch is an electric constant tension winch device, model ZL-500, with a rated lifting force of 5 kN, equipped with a dual braking system (electromagnetic power failure braking + mechanical disc brake) and an encoder feedback closed-loop control module. Its winding reel is a cast steel drum with spiral guide grooves to ensure orderly arrangement of the wire rope, without overlapping or skipping. The rope is a stainless steel wire rope, one end of which is firmly pressed to the end of the winding reel through a pressing collar, and the other end is reliably connected to the lifting lug plate pre-embedded at the end of the support seat through a metal rope clamp. The effective working length of the rope is configured with a redundancy of 1.3 times the maximum lifting stroke of the support seat to avoid premature slack and instability under extreme working conditions.

[0048] A fixed platform provides a stable high-position fulcrum, while the winch, as the active drive unit, outputs controllable winding and unwinding actions. The rope, acting as the force transmission medium, converts the winch torque into a vertical upward pulling force on the end of the support base. When the winch tightens the rope, the support base rotates counterclockwise around its distal hinge axis (i.e., the fulcrum connected to the other end of the simulated well shaft 14), causing the entire simulated well shaft 14 to tilt synchronously. When the rope is loosened, gravity returns the shaft to its original position. This lever-pulley composite mechanism, consisting of these three components, provides self-locking, fine-tuning, and disturbance resistance during angle adjustment. It allows the simulated well shaft 14 to cover a full range of 0° to 90°.

[0049] See Figure 1As shown, a viewing window 19 is provided on the side wall of the simulated wellbore 14. The viewing window 19 has graduations perpendicular to the axis of the simulated wellbore 14, used to measure the height of the cuttings bed. This embodiment achieves direct observation and quantitative measurement of the cuttings bed accumulation state inside the wellbore by integrating a graduated viewing window 19 structure into the side wall of the simulated wellbore 14. The viewing window 19 is located on the side wall of the simulated wellbore 14 in an area prone to cuttings deposition, allowing for comprehensive capture of the entire cuttings transport process. The viewing window 19 is made entirely of transparent material, specifically quartz glass or high-strength sapphire glass. These materials possess excellent high-temperature and high-pressure resistance while maintaining good optical transmittance, ensuring clarity for external observation and video recording. Through this technical solution, visual monitoring and precise measurement of the cuttings bed height are achieved under high-temperature, high-pressure, and inclined wellbore environments. The inclusion of a viewing window 19 with vertical scale lines allows for a direct visualization of the rock cuttings deposition behavior previously confined within the metal wellbore, solving the technical challenge of traditional experimental devices being unable to acquire real-time rock cuttings bed morphology parameters. This enables researchers to adjust drilling fluid performance parameters or optimize tripping and tripping procedures based on actual observation data, providing experimental evidence for safe and efficient drilling of complex well types.

[0050] See Figure 1 As shown, a method for simulating oil drilling experiments, based on the above-mentioned device, includes the following steps: Step 1: By cooperating with the lifting assembly 1 and the support base, adjust the lifting height of one end of the simulated well shaft 14 to achieve the preset inclination angle of the simulated well shaft 14; The lifting assembly 1 includes a winch, a fixed platform, and ropes. The support base is used to support the simulated wellbore 14 and the linear movement assembly. By controlling the winch to wind up and unwind the ropes, one end of the support base is raised or lowered, thereby changing the tilt angle of the simulated wellbore 14 relative to the horizontal plane. The well tilt angle can be set arbitrarily within the range of 0° to 90° to cover various well types and working conditions, such as vertical wells, inclined wells, and fully horizontal wells.

[0051] Step 2: Inject rock cuttings of the corresponding particle size from one end of the simulated wellbore 14 to form a rock cuttings bed at the bottom of the simulated wellbore 14. At the same time, measure the injection height of the rock cuttings and adjust the height of the rock cuttings bed to the target value. The rock cuttings are made of quartz sand, ceramsite, or artificial low-density granular materials, with a particle size range that can be configured according to the target lithology, such as 0.2mm to 4mm, to simulate formation products with different degrees of fragmentation. The rock cuttings are filled through the opening at the right end of the simulated wellbore 14 and naturally settle to the bottom under gravity, forming an initial rock cuttings bed. The sidewall of the simulated wellbore 14 is equipped with a viewing window 19, allowing operators to monitor the rock cuttings accumulation height in real time via visual inspection or image recognition technology. Once the preset height is reached, the end sealing flange is closed and the dynamic sealing assembly is activated to prevent leakage during subsequent pressurization.

[0052] Step 3: Pour the prepared drilling fluid into the simulated wellbore 14 and fill the entire simulated wellbore 14; The drilling fluid can be selected from water-based mud, oil-based mud, or synthetic-based drilling fluid according to experimental requirements. Functional agents such as viscosifiers and filtration loss reducers can be added to regulate its rheology and proppant carrying capacity. The density of the drilling fluid is controlled at 1.25 g / cm³. 3~ 2.0g / cm 3 The viscosity is controlled between 20 mPa·s and 27 mPa·s. The drilling fluid is injected into the simulated wellbore 14 through the drilling fluid injection unit until all air is purged and the entire annular space is filled. To ensure the system's airtightness, the inlet is equipped with a check valve and a pressure buffer tank to prevent backflow and pressure fluctuations.

[0053] Step 4: Activate heating coil 6 to heat simulated wellbore 14 to the target temperature; activate high-pressure gas circuit assembly to achieve the target high-pressure environment inside simulated wellbore 14; The heating coil 6 is arranged around the outer wall of the simulated wellbore 14. When energized, it generates Joule heat, achieving uniform heating. The heating coil 6 is connected to a temperature controller, which, together with the temperature gauge 7 installed on the simulated wellbore 14, forms a closed-loop temperature control system. The high-pressure gas circuit assembly includes a high-pressure air compressor 10, a gas storage tank 11, a pressure regulating valve 18, and a gas delivery pipeline. Pressure is applied to the wellbore by compressing an inert gas (such as nitrogen). The outlet pressure gauge 178 and the pressure gauge 8 inside the wellbore jointly monitor pressure changes to ensure a controllable pressure gradient. The target temperature and pressure can be set independently or applied simultaneously to simulate the actual downhole thermodynamic path.

[0054] Step 5: Set the rotational speed and moving speed of the simulated drill rod 15, and then start the rotary drive and linear motion component in sequence to drive the simulated drill rod 15 to move; The rotary drive is either a servo motor 2 or a stepper motor, connected to the output shaft of the simulated drill rod 15. The linear motion component includes a rotary motor, a gear 22 transmission platform 12, and a rack 20 guide rail 21, achieving axial reciprocating motion of the simulated drill rod 15 through gear 22 and rack 20 meshing. The control system supports programmed operation modes, such as constant speed drilling, intermittent pulling, and rotary sweeping sequences. The startup sequence is typically to first activate the rotary drive to bring the drill rod to the set speed, and then activate the linear motion component for axial feed, avoiding excessive static friction that could cause equipment impact.

[0055] Step Six: Every 2-5 seconds, use tension / compression sensor 2 to collect the tension / compression data during the simulated drilling process of drill pipe 15, and use torque sensor 3 to collect the torque data during the simulated drilling process of drill pipe 15. A high-speed camera is also used to record the cuttings transport process in real time.

[0056] The tensile and compressive force sensor 4 is installed at the connection between the simulated drill pipe 15 and the transmission mechanism to measure the changes in axial tensile and compressive force during the tripping process in real time, reflecting the magnitude of friction and the tendency of jamming. The torque sensor 3 is integrated into the rotary drive system to detect the torsional torque on the drill pipe and evaluate the wellbore cleaning effect and the degree of cuttings interference. The multi-source data acquisition module synchronously acquires parameters such as temperature, pressure, rotational speed, and displacement, and stores them as structured files through the data acquisition instrument for easy statistical analysis later. At the same time, a high-speed camera is aimed at the viewing window 19 and captures the process of cuttings bed disturbance, particle transition, and agglomeration separation at a rate of hundreds of frames per second. The transport velocity field and concentration distribution are extracted by combining image processing algorithms.

[0057] Through the above-described steps, this invention achieves a systematic and standardized simulation of the entire horizontal well tripping process under high temperature and high pressure conditions. By controlling the well inclination angle, cuttings bed height, drilling fluid properties, temperature and pressure environment, and drill string motion parameters step by step, the influence of a single variable on friction torque and cuttings transport behavior can be examined individually. Multi-factor coupled experiments can also be conducted to reveal the nonlinear response mechanism under complex deep working conditions. This method not only improves the repeatability and data reliability of the experiments but also provides a reliable experimental foundation and technical support for drilling process optimization, anti-sticking early warning model construction, and evaluation of new drilling fluids.

[0058] Under rotary drilling conditions, the simulated drill pipe 15 exhibits both axial movement and rotation. Therefore, the frictional resistance and axial force during the drilling process can be calculated using the following formula: Due to the influence of high temperature and high pressure conditions, the coefficient of friction is: Frictional force acting on the drill pipe: Torque on the drill pipe: f The comprehensive friction coefficient; F This represents the frictional resistance experienced by the unit tubing; it is "+" during tripping in and "-" during descent. T 1 represents the axial force at the upper end of the drill string unit; T 2 represents the axial force at the lower end of the drill string unit; M The torque is the drill string torque, in N•m; N This is the contact normal force between the drill string and the wellbore. D o The outer diameter of the tubular column; f c This represents the directional component of the overall friction coefficient on the circumference. W This represents the weight of the drill string in the drilling fluid. f o It is the coefficient of friction at room temperature and pressure. These are the coefficients of influence of temperature and pressure on the coefficient of friction, respectively. These are the temperature and pressure changes at the current location, respectively. Axial velocity of the micro-element (m / s). Rotational speed (r / min) is the coefficient of thermal expansion. Current location x The temperature at that location. Room temperature (reference temperature). Current location x The pressure at the location. At atmospheric pressure (reference pressure). Current location x Positive pressure at the location.

[0059] Obviously, those skilled in the art can make various modifications and variations to this invention without departing from its spirit and scope. Therefore, if these modifications and variations fall within the scope of the claims of this invention and their equivalents, this invention also intends to include these modifications and variations.

Claims

1. A petroleum drilling simulation experiment device comprising a simulated wellbore filled with cuttings inside for simulating a cuttings bed, characterized in that, Also comprising: a high-temperature and high-pressure control unit, comprising a heating coil sleeved on the outer wall of the simulated wellbore and a high-pressure gas path assembly connected with the simulated wellbore, the heating coil being used for simulating the temperature in the well, and the high-pressure gas path assembly being used for simulating the gas pressure in the well; a tripping simulation unit, comprising a rotary driver, a linear moving assembly and a simulated drill pipe, the simulated drill pipe being movably arranged in the simulated wellbore, the rotary driver being fixed on the output end of the linear moving assembly, and one end of the simulated drill pipe extending out of the top end of the simulated wellbore and coaxially connected with the output shaft of the rotary driver, the linear moving assembly being used for driving the simulated drill pipe to move along the axial direction of the simulated wellbore, and the rotary driver being used for driving the simulated drill pipe to rotate; a well inclination angle adjusting unit, comprising a lifting assembly and a support seat, the simulated wellbore and the linear moving assembly being arranged on the support seat, and the output end of the lifting assembly being hingedly connected with one end of the support seat, so as to change the inclination angle of the simulated wellbore by adjusting the lifting height of the one end of the support seat; a drilling fluid filling unit, the output end of which being in sealed communication with the simulated wellbore, and being used for injecting drilling fluid into the simulated wellbore.

2. The experimental apparatus for simulating oil drilling according to claim 1, characterized in that, The high-pressure gas path assembly comprises: a high-pressure air compressor, having an air inlet and an air outlet, and a pressure regulating valve being arranged on the air outlet of the high-pressure air compressor, so as to regulate the gas output pressure; a gas storage tank, the air inlet end of which being in communication with the air outlet of the high-pressure air compressor, and the air outlet end of which being in sealed communication with the simulated wellbore through a gas pipeline, so as to output high-pressure gas.

3. The experimental apparatus for simulating oil drilling according to claim 2, characterized in that, The air inlet of the high-pressure air compressor is provided with an air inlet pressure gauge, so as to monitor the air inlet pressure in real time, and the air outlet is provided with an air outlet pressure gauge, so as to monitor the gas output pressure before pressure regulation in real time.

4. The experimental apparatus for simulating oil drilling according to claim 2, characterized in that, The linear moving assembly comprises: a rotary motor, being fixed on the support seat; a gear, being sleeved and fixed on the output end of the rotary motor; a gear transmission platform, comprising a rectangular frame and two racks fixed on opposite sides of the rectangular frame respectively, the two racks being arranged in parallel with the simulated drill pipe, the gear being engaged with the two racks, and one end of the simulated drill pipe extending out of the simulated wellbore being fixed with the rectangular frame through the rotary driver; a guide rail, being fixed on the support seat, and the rectangular frame being in sliding connection with the guide rail.

5. The experimental apparatus for simulating oil drilling according to claim 4, characterized in that, Further comprising a processing unit, the processing unit comprising a controller and a multi-source data acquisition module, the multi-source data acquisition module being used for acquiring the rotating speed and moving speed of the simulated drill pipe and the gas pressure and temperature inside the simulated wellbore, the controller being electrically connected with the rotary driver, the rotary motor, the pressure regulating valve and the heating coil respectively, and the controller being used for adjusting the parameters of the rotary driver, the rotary motor, the pressure regulating valve and the heating coil according to the feedback data of the multi-source data acquisition module, so as to realize closed-loop control of the parameters.

6. The experimental apparatus for simulating oil drilling according to claim 5, wherein, The multi-source data acquisition module comprises a torque sensor, a tension and pressure sensor, a thermometer and a pressure gauge, the torque sensor and the tension and pressure sensor are arranged on the simulated drill pipe, the torque sensor is used for measuring the rotating speed of the simulated drill pipe, the tension and pressure sensor is used for measuring the moving speed of the simulated drill pipe, and the thermometer and the pressure gauge are respectively installed on the simulated wellbore and are used for measuring the temperature and the air pressure in the simulated wellbore respectively.

7. The experimental apparatus for simulating oil drilling according to claim 5, wherein, The hoisting assembly comprises: a fixed table arranged above the support base and higher than the simulated wellbore; a winch arranged on the fixed table and having a winding wheel; a rope, one end of which is connected with the winding wheel of the winch and the other end of which is fixed with one end of the support base, for realizing the lifting of one end of the support base through the forward and reverse rotation of the winch.

8. The experimental apparatus for simulating oil drilling according to claim 5, characterized in that, The sidewall of the simulated wellbore is provided with a visual window, the visual window is provided with a scale along a direction perpendicular to the axis of the simulated wellbore, the zero point of the scale is flush with the inner wall bottom of the simulated wellbore, and the scale is used for measuring the height of the cuttings bed.

9. A method for simulating oil drilling experiments, implemented on the basis of a device according to any one of claims 5-8, characterized in that, The method comprises the following steps: adjusting the lifting height of one end of the simulated wellbore through the cooperation of the hoisting assembly and the support base, so that the hole inclination angle of the simulated wellbore reaches a preset value; injecting cuttings with a particle size of 0.1mm-4.0mm from one end of the simulated wellbore to form a cuttings bed at the bottom of the simulated wellbore, and simultaneously measuring the injection height of the cuttings, so that the height of the cuttings bed is adjusted to a target value; The prepared drilling fluid with density of 1.25 g / cm 3~ 2.0 g / cm 3 , viscosity of 20 mPa·s~27 mPa·s is input into the simulated wellbore and fills the entire simulated wellbore; starting the heating coil to heat the simulated wellbore to a target temperature, and starting the high-pressure gas path assembly to make the simulated wellbore reach a target high-pressure environment; setting the rotating speed and the moving speed of the simulated drill pipe, and sequentially starting the rotary driver and the linear moving assembly to drive the simulated drill pipe to move; every 2s-5s, the multi-source data acquisition module is used to collect the tension and pressure and torque data in the drilling process of the simulated drill pipe, and the cuttings migration process is recorded in real time.

10. A method according to claim 9, wherein, The angle range of the hole inclination angle is 0°-90°.

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